Dual flowing device



Nov. 21, 1950 o. CRANFILL 2,531,253

mum. FLOWING DEVICE k Filed March 5, 1946 s Shets$heet 1 I m/entor 0775('TA NF/Ll.

WWW 3% Filed March 5, 1946 3$heBtS-Shee1f2 Nov. 21, 1950 o. CRANFILL2,531,258

DUAL FLOWING DEVICE Inventor 07/5 C3 24 NF'ILL By ghee/Zia wig way 3mNov. 21, 1950 o. CRANFILL mum. FLOWING DEVICE Filed March 5, 1946 3Sheets-Sheet 3 llllill Ill Alli!!! .lflI u I I I 'I If! 7"! II III! 7",:III! I I I I I l I. II I 7 I If" I I!!! III .III III! IIIIIIIIIII i Ill!.Illll/ll I! vlill. .vl Itillllifli Illl'llilllll'lli I I I .0 I I. I .lI v! I r VIII/l, III! ilfllirilifivlvl ll I III. ,II.

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Patented Nov. 21, 1950 UNlTEosTAT-Es PATENT OFFICE DUAL FLOWING DEVICEOtis Cranfill, Groes beck, Tex., assignor of onehalf toB. F. Weekley,Fort Worth, Tex.

Application' March 5, 1946, Serial No. 652,048

, 4 Claims. 1

This invention relates to new and useful improvements in oil wellequipment and more particularly to a dual flowing device for oil and gaswells having a plurality of productive zones, strata or productive payareas in one well. In certain localities, there is often found two ormore productive pay areas at different depths in one well and thepresent invention is designed to facilitate and control the flow fromsaid areas simultaneously or independently, and to facilitate therunning and pulling or removal of the piping, especially in very deepwells, and where the distance between the respective productive payareas is considerable and the length and weight of tubing becomes aproblem, especially in sealing off the productive areas from each otherfor independent flow control or in elevating the upper inner tubing topermit simultaneous flow of both areas through the same outlets.

The principal object of the present invention is to provide a novel andeflicient device whereby two pay areas or stratums can be producedsimultaneously or separately, if desired, or to permit the areas orzones to be successively and independently swabbed in or made to flowthrough the tubing, and wherein when the flow is established, thepressure of the gases in the different areas or zones may be used tofacilitate and provide the necessary pressure for insuring the flow andproduction from either or both areas.

Another important object of the invention is to provide a dual flowingdevice of the character as stated, which can be inserted into an oilwell casing which houses the oil well tubing having the usual casinghead, Christmas tree and rigging, for the purposeof permitting eitherone of the two pay areas to produce and flow separately, or to permitbothare'as to produce orflow simultaneously. 1

A still further object of theinvention is to facilitate the running ofthe piping or tubing and pulling or removal thereof, especially, in verydeep wells, where the distance between the areas is considerable, and toproduce and facilitate a combination dual installation in wells ofextreme depth due to the extreme weight of the tubing, and makethe'saine much less hazardous and much less likely of parting whenrunning the tubing and for sealing off or establishing communicationbetween the respective independent production or pay areas withoutallowing A still furtherlobject of the invention is to facilitate therunning of the tubingorpulling of the upper section thereof with respectto the inside tubing, for the flow of oil and gas from the deepest oilbearing formation or stratum constituting a productive pay area, byhaving the inside tubing divided into two parts so that the same may beconnected with facility or separated so that the pressure from either orboth productive pay areas may be used to provide the necessary pressurefor causing the flow or discharge of the gas or oil from either area andto conserve the pressure for a longer time duration, as well as topermit the use of plain tubing instead of upset tubing for the insidetube in order to maintain an ample annular space for the top pa 'toproduce through to the surface, and to guide and keep the sections ofthe tubing in alignment at all times to facilitate the running andpulling thereof, without necessitating a fishing job.

This application is a continuation in part of my prior applicationSerial No. 473,759, filed January 27, 1943, now abandoned.

Other objects and advantages reside in the details of construction andoperation as more fully hereinafter described and claimed, referencebeing had to the accompanying drawings .forming part hereof, whereinlike numerals refer to like parts throughout, and in which:

Figure 1 is a vertical sectional view of the barrel or cylinder of thedual flowing device constituting the invention.

Figure 2 is a side view in elevation of the upper core of the sealingdevice.

Figure 3 is a bottom end view of the core shown in Figure 2.

Figure 4 is a longitudinal sectional view of the structure shown inFigure 1, taken substantially on the line i i thereof and showing theconnection for the lower outer tubing section.

Figure 5 is a side iew in elevation of the sealing head of the device.

Figure 6 is a bottom view of the structure shown in Figure 5.

Figure 7 is a vertical longitudinal sectional view showing the dualflowing device installed in a well casing of a well having twoproductive pay areas, and the parts positioned to isolate the fluidflowing from one fluid bearing stratum from that flowing from anotherfluid bearing stratum, and

Figure 8 is an enlarged fragmentary sectional view of the device showingthe parts positioned to permit simultaneous flow of fluid from bothstrata through the tubular conduit oi the device.

Referring to the drawings in detail and particularly to Figures '7 and8, a conventional well is shown as passing through a plurality of oilhearing or productive pay areas or strata, indicated as an upper oilbearing formation or stratum B and a lower oil formation or productivestratum C. The ground level is designated at D, above which the casing,and oil flow control devices. extend. Conventional well rigging isdisposed above the well and is equipped with con.- ventional means forraising or lowering the tubular conduit, tube and the well casing in amanner well known in the art. The well is cased with a conventional wellcasing A which is: provided with spaced groups 25 and- 25 ofperforations through which the fluid from. the respective strata B and Cma enter the casing A.

Referring more especially to Figure 4' of the drawings, as well as toFigures 1 and 7, the numeral designates a barrel or cylinder of tubingconstituting a portion of the outer tube of the device. This tube may beof any suitable diameter, less than the i. d. of the well casing, suchfor example as 2 /2", so as to provide an annular space between the tubeand the well casing A. This barrel 5, like the other sections of thetube is preferably of the plain tubing typ and is externally threaded atits upper end to connect to an internally threaded coupling into whichis threaded a perforated sub-barrel or tube section be. The upper end ofthe perforated tubing section to is coupled in a conventional manner asby coupling 53a to an upper string or run of tubing 5b which extendsabove the upper end of the casing A of the well in the usual manner.

As best seen in Figure 7, the tubular well casing A extends from abovethe top of the ground to the bottom of the well, through an upper paylayer or oil producing stratum B and right down into and through thelower pay or oil producing stratum C, which may be as deep down as 4,000below the upper oil producing stratum B, which itself ma be locatedseveral thousand feet below the ground level C; As indicated in Figure'1, the well casing A is provided with a group of perforations 25 toestablish. communication between the upper stratum B and the interior ofthe casing and this casing A is also provided with a longitudinallyspaced group of perforations 26 which open into the lower stratum. C.The upper end of the casing A terminates slightly above. the groundlevel D and is closed by a cap A of" any preferred construction. The capA is provided with an axial opening through which. passes the end of thestring or run of tubing 517: remote from the perforated section 5a.

Numeral 7 indicates a mandrel or piston body which constitutes asection. of the inner tubing or tubular conduit and has a centralpassageway 21 throughout its entire length terminating near its upperend in an enlarged oppositely tapered guide portion or cup protector 8having a tube portion or extension corresponding to portion T, atitsupper end, where it is externally threaded as at 8a to accommodateand removably attach to an. internally threaded collar to by means ofwhich the upper end or section Ia of the smaller inside tubing ortubular conduit is attached to form a continuation of the centralpassageway 21 and extend above the head 50 of the outer tubing andsection 51) thereof, through and above said head, where it may beattached to suitable rigging or elevating means so that it may be movedup or down. In this way, the upper section Ta of the inner tubingextends movably through the head 50 constituting the closed upper end ofthe barrel constituted by the sections 5, 5a and 5b, and in spacedrelation coaxially within said barrel or tubing.

Numerals 9, 9, denote a plurality or pair of packing or sealing cupssimilar to those used on pistons and may be of the standard Darcona typeon the hollow lower portion of the mandrel or piston body 1' facinginone direction, while numerals 19, I0, denote another pair or pluralityof similar cups on the same lower portion of the mandrel or body 1facing in the opposite dimotion-- to the cups 9, 9. A fiat metal spacerring H is placed between the opposite ends of the adjacent cups 9 and I0and is slightly smaller than the interior diameter or bore of the outertubing toreadily move therein while causing proper spreading of thesealing or packing cups.

Other necked metal spacers Ha fit around the mandrel or piston body 7with their necks seated within and between the cups of said pairs of cuppackings 9 and M respectively, as more particularly shown in Figure 4 ofthe drawings.

The lower end of the tubular mandrel or piston body I is externallythreaded to engage the internally threaded neck portion P2 of a cupsupport guide or head [3 which is also tapered in opposite directionsand has a smooth faced tubular downward extension or nipple M providedwith a lead packing l5 adjacent its lower reduced portion at thejuncture of the lower tapered or beveled end thereof, forming a seal forthe internal upwardly facing seat 16 of a top sealing collar which hasan internally threaded enlarged upper end threaded on the externallythreaded lower end' of the barrel 5. The guide [3- has the passagewa 21continued therethrough by reason of the hollow bore 2-!- forming acontinuation of said passagewa through the mandrel or rod 7. The tubularconduit includes the sealing device or piston, and consists therefor ofthe following parts, namely"; 1, la, 8, 8a, 8b, 9, I8, II, Ila, l2, l3,l4 and f5, and the inner sealing section or tube consists of the parts5, 5a, 5b, 5c, 6, 6a, and I6.

The lower portion of the seat It is thickened and smooth internally toreceive the portion Id of the seat body 13' and has a reduced ex ernallythreaded portion to accommodate the internally threaded portion. at theupper end of a combination hanger sleeve H which has an internallythreaded axial socket opening into an axial threaded bore which extendsdownwardly through a reduced externally threaded lower portion. Thejunction of the socket and bore form a shoulder l8 for supporting atubular hanger l9 having a reduced internally threaded extension ornipple 21' by which the upper" externally threaded end of a lowertubular conduit section lb is connected thereto. The hanger also has anaxial internally threaded socket entering its top into which is threadeda short externally threaded nipple 20. This nipple 29 extends up intothe recess Hia' provided in the lower portion of the seating collar 16.The hanger l9 as before stated, is internally threaded as at 2| toreceive the upper threaded end of the lower section lb of the. tubularconduit. which corresponds in diameter to the mandrel 1. The lowerreduced and externally threaded end of the hanger sleeve or collar I Thas a lower barrel section or tube Ila. corresponding in size to themain. barrel section 5. connected thereto by means of an internallythreaded collar 61) corresponding to the collar 6 at the upper end ofthe barrel 5 and by which the latter is connected to the perforatedtubular section a so that the lower tubular barrel section Ila of theouter tubing is connected to the hanger seat l1.

With two oil paying or bearing formations producing productive areas orzones, one a considerable distance below the other in the well, asdescribed, a suitable packer or outer tubing head 4, such as bronze,provided with a packing ring, is placed or fixed on the lower barrelsection or tubing Ila between the well casing A and the lower barrel ortubing section Ila so as to seal off the annular space between thecasing A in the lower barrel at a point between the strata B and C asshown in Figures 7 and 8, to prevent any upward flow of theoiltherebetween. However, above the packer 4, the casing is perforated asat 25 where it passes throughthe upper oil producing area B so thatoilcan be produced from the upper area and allowed to flow through otherperforations 25a provided higher up in'the inner tubing section orbarrel Eaand then flew upwardly in the annular space 250 between theinner tubing 1a and the outer tubing or barrel 5b above the sealingdevice or piston within the outer tubing. The lower oil producing orpaying area isdrained by passing the'oil through the perforations 26 inthe bottom end of the casing A and then through the perforations 26a inthe tapered lower end or nozzle of the lower outer tubing section orbarrel Ila and up through the inner tubing starting with the lowersection lb as shown in Figures 4 and 7, this flow being entirelyseparate from the flow in the casing A above the packer or outer pistonhead 4, constituting a sealbetween the outer tubing at Fla and the wellcasing A. It will thus be seen that the separable dual flowing deviceand inner seal is so constructed as to establish a continuous innertubing passage connecting the sections la and lb, of uniform size andrela- 6, turning the same to couple or uncouple the same at the threadedconnections with positive alignment insured to facilitate same as abovedescribed and prevent dropping of the lower section or unit to avoid thenecessity of a fishing .job.

The oil from the upper oil producing area B is caused to flow underpressure of the gases from the sands therein for discharge separatelyfrom the oil from the lower oil producing area C,-and takes placethrough the perforationsin the well casing A to the space of annularform between the same and the outer tubing at the cylinder or barrel 5and then through the perforations 25a of the barrel or tubing sectionsarand annular space 250 around the inner tubing section la, fordischarge through the delivery pipe 30 at the top, where the pressuremay be-determined by a pressure gauge 3|. As distinguished from thebottom oil supply, the top oil supply through the annular passage, willbe underapressure of .thegases above the packer A, and at the top of thespace between the outer tubing and the well casing at the top, where thepressure may be determined by another pressure gauge 32 in the space25b, permitting the pressure to be stored or back up; therein in orderto facilitate the flow from the upper ,oil bearing formation or area B,and in each instance, to conserve the pressure for a longer time.duration. Avery important feature of ,thisinvention is the hangerconstruction.v *The upper or inner sealingsection or piston terminatesat the lower end with the tube nipple M. :For very deep wells, a tubularconduit section lb is needed to reach downinto the lower oil deposit atC, and this tively smooth bore, sealed oil from the annular passagetherearound, between the inner tubing and the outer tubing to allowseparate or independent fiow of the oil therethrough from the the casingA and the perforatedlower end of the nozzle or outer tubing and then upthrough I the central smaller tubing or passageway -2l. In thisoperation and relation of the-parts as shown in Figures 4 and 7, thelead seal I5 supplemented by the sealing rings or cups 9 and It,eifectively seal on" the annular space or passage between the innertubing and the outer tubing in the lower portion of the-casingA, and thecorresponding space or passage in the upper portion of the casing abovetheseparable dual flow device of the present invention so that the flowis entirely-through the inner tubing or passageway 2'! independently ofthe annular passage therearound, with the discharge through the oildelivery pipe '28, while the pressure may beidetermined by the gauge 29.Obviously, a Christ-.

mas tree or any other suitable arrangement may beprovided at thetop forcontrolling the now and for raising and lowering the upper section ofthe inner tubing and the sealingtdevice, as

well as for running or pulling the tubing and for tubular conduitsection"; is threaded in the hanger l9 and has the same bore as the maintubular mandrel and the nipple 2fl. The'advantage of this arrangementwill be readily seen as when assembling or removing the..tubular conduitin the oil well, the nipple will serve as a coupling by which thelowertubular section may be attached to: suitable hoist mechanism andtheweights to be handled may be materially reduced. Supposing, forinstance, that ,the casing A has beeninstalled in the well together withthe lower parts 4, Ila of the lower or outerv sealing section to thehanger sleeve and seat I1, then it will be possible to lower the hangerI9 with the attached tube section 11) therein, suitable implements beingused-for gripping the threaded stubpipe 20 during this procedure.Subsequently the collar seat is with barrel 5 is added and thenthe innersealing section proper from the support guide head l3 up is lowered intoits seat l6.

By this means a two-stage installation is possible; with the innertubular conduit comprisiing parts 1,100, lbjin perfect alignment and theweight of the lower part lb and hanger is supported on the hanger seat[8. i The tubular con- ;duit comprising the parts from the support guidehead [3 up are supported by the .lead packing [5 in the collar orpistonseat It. By thus sup- ;porting thetubular conduit at spaced pointsthe running and pulling thereof in deep wells is ,;made less hazardous.

Another advantage is that raising of'the oil from the bottom layer takesplace through a relatively small conduit, about 1%; diameter, while theraising of the oil fromthe upper ;de-

posit takes place through arlarger tube, about 2 diameter. r i

n :Fi .1116: .iO the r wineathe dual fl l r sea ing; device is. shownparted or; separated atv the lead seal t5; to. permit, simultaneousorjointflow from. both. oil producing; areas through. the upper portion ofthey annular flow passage or. space and theinner tube or passage, as.Well as facilitating running or pulling of the tubing or piping in deepwells; and permitting the. flow from. the upper and: lower pay orproduction. areast beswabbed inin the customary manner: andso that. theoil or.- fluid entering above. the; swab. may be: lifted out; in the.nature. of bailing to. induce. the flow ofthe oil out of the formation.to the surface of the ground through. the well for storage. Especially'is thistrue when it' is. necessary to swab in the bottom myarea. or production formation and. in. washing. outzthe. mud with waterand the water with oil. The. device: also; cuts the gas waste down in.lifting the; fhiid due. to: smaller columns thereby reducing the gas.breaking through the fiuid and allowing the well. to. flow longer on itsown gas: reserves, thereby lengthening the life of thewell flushoutputto someextent. It also completely eliminates the cost. of drillinga second well and the material required in connection therewith.

Under certain circumstances and particularly for cleaning in the case ofvery deep wells, it is necessary to pull up the inner sealing or pistonstructure including the support guide head: l3 where it is seated at [5as shown in Figures 1, 4 and-'7. It might become necessary to switch orchange joints at thetopin order to equally divide the weight at the seall5 and the usual Christmas tree hanger at the-well surface (not shown)This would likely be necessary on each installation while making theinstallment, but after the completion of this-installmentand the deviceis in position, as-shown in Figure l, itis in this position that it isreadyto function and serve its purpose as a means of closing the annularspace of the tube 5 and the outside of the smaller tube line below thehanger seat H.

A separate deposit of fluid from the top stra- B, (as isclearl y shownin Figure 7) is made in the casing A outside of the large-tube 5-through the useof the packer'and the dual'fiowing device, which makes-itpossible toconfine the fluids. from difierent strata to separate linestostorage vessels. The-fluid from the bottom deposit C passes through thebore-2 1 of the tubular conduit Ta to the surface line-2'8 andcorresponding storage vessel, while the fluid from the top stratum Bpasses through the flow. passages 25a in the tube section 5a to theoutside of the tubular conduit Pa and hence it will be seen that thefluids from the two strata will be prevented from -mingling. Whenhowever it is desired to discharge the fluids-from both strata, thetubular conduit la together with the head t3 and packing rings-9- ismoved longitudinally of the tube section untilit passes through the tubesection 5a having the flow passages 25a and into the tube section 512.In this position it will be evident that the fluids from both strata B.and C will be di schargedfrom the well through the tubular conduit.

While the foregoing specification sets forth the invention inspecificterms, it is to be. underhole from thebottom thereof to: the surfacerof.the ground and having, a perforated area at each. of said stratums,outer. flow, tubing; disposed within and in spaced concentric relation,to said casing extending: continuously from the bottomv of the well toapointabove the top. of. said: casing, a packeron said. outerflowtubing: engaging the casing between theperforated. areasforisolating the stratums from each other with respect to the space-betweenthe casing and the outer flow tubing, said outer flow tubing having aperforated area above-the packerand adjacent the upper perforated areaof the casingand being provided with an internal valve seat below saidperforated area in the outer flow tubing, an inner flow tubing includinga lower section open at' its lower end hung in the lower portion of theouter flow tubing below said. valve seat and extending downwardly to apositionadjacent the lower perforated area in the casing. and an uppervertically morable. section separate fromv the lower section. ex.-tending above the outer flow tubing and having anexternal valve head onits. lower end engageable with said valve seat when said upper sectionis lowered, said upper section further having packing means on: its;lower portion sealingly engaging the outer flow tubing and. selectivelymovable to a position above or av position; below the perforated area ofthe; outer flow tubing by raising or lowering said upper section,whereby communicationmay be established between the inner flow tubingand both stratums or communication may be established between the innerfiowtubing and the lower stratum only whilesimultaneously establishingcommunication between the outer flow tubing and the upper stratum only.

2. The construction defined in claim I, wherein the upper section of theinner flow tubing has a reduced neck on itsv lower end adapted to entera restricted passage of the outer fiow tubing below said valve seatwhen. said valve head is engaged with the latter.

3. In. a dual flowing device for a. well hole which. passes through twovertically spaced oil producing stratums, comprising a. casing liningthe well hole from the bottom thereof to the surface of the ground andhaving upper and lower spaced perforated areas therein for communicatingwith the stratums, an outer flow tubing. disposed'within and in spacedconcentric relation to the casing, a packer surrounding the outer flowtubing and. in sealing engagement with the easing at a location betweenthe perforated areas in the casing, said outer tubing having a fluidinlet below the packer and having a perforated area therein at aposition above the packer, an inner flow tubing open at its lower enddisposed within and in spaced concentric relation to the outer flowtubing, a packing member surrounding and fixed to the inner flow tubingthat sealingly engages the outer fiow tubing, said inner flow tubingbeing vertically movable in the outer flow tubing to selectivelyposition the packing member above and below the perforated area of theouter flow tubing, whereby communication may be established-between the.inner flow tubing and both stratums; or communication may be establishedbetween the inner flow tubing and the lower stratum. only whilesimultaneously establishing communication between the outer flow tubingand the. upper stratum only.

4. The. construction defined in claimB, wherein heads close the. upperends; of'thecasing and the flow tubings, in combination with oildelivery file of this patent:

UNITED STATES PATENTS pipes communicating with the upper end por- NumberName Date the tubmgs- 1,871,319 Griswold Aug. 9, 1932 OTIS CRANFILL-2,274,407 Hammer Feb. 24, 1942 5 2,277,380 Yancey Mar. 24, 1942REFERENCES CITED 2,403,987 Lewis July 16, 1946 The following referencesare of record in the 3 39 Bridwen et a1 Sept-h 30) 1947

